US10991041B2 - Next-generation energy market design and implementation - Google Patents
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Definitions
- the present disclosure relates generally to the design and implementation of next generation electricity market systems that support competitive trading of electric energy and ancillary services within day-ahead and real-time market operation frameworks.
- the present disclosure relates to constructs, systems, processes and methods of ensuring electric power system reliability while maximizing economic efficiency of electricity market operation and providing competitive market commodity clearing prices.
- this disclosure is directed toward systems and methods for the next generation of electricity market systems to provide advances in system reliability, market efficiency and solution quality while considering smart grid technologies that bring in distributed, decentralized grid asset data and information, and while facing large numbers of a variety of market participants and system user groups.
- the invented systems and methods leverage market operation experiences and utilize advances in information technology, optimization techniques, computation capabilities, and man-machine interaction.
- the discloser may support further evolution of electricity market policy, design, and deployment in a variety of market operation settings.
- the architecture of disclosed system supports the external and internal data transfers, input/intermediate/output data archival, save case management, multiple market execution workspaces, and a tree of solution sequences. Also, the computation capabilities of multi-processor and multi-thread servers support parallel information processing within market execution timeline for advanced market features and mathematical models of business objectives and physical characteristics. The advanced system architecture mitigates limitations on timely achievement of overall market operation optimality which currently available systems cannot provide.
- the invented system is configurable to be capable to support a variety of electricity market arrangements, market design rules and market commodity settlement determinants.
- the execution timeline is configurable to accommodate execution times, time interval lengths and trading period duration suitable for day-ahead and real-time market frameworks.
- the functionality and setting parameters of the system are configurable to support clearing and pricing for multiple market commodities as well as optimal resource commitments to maintain system reliability in day-ahead and real-time markets.
- the invented system creates a separate workspace for every market run in operation or study environments.
- the operation workspace is restricted to the market operator, supervisor and monitor users, while study workspaces can be used by a variety of analysts and auditors.
- the viewing and editing permissions depend on user authority and data privacy policy.
- a solution sequence tree can be created for a variety of objectives and strategies of analysis.
- a tree branch can be added and any tree leaf can be selected as the final solution at any point of time.
- a branch of the solution sequence is created according to the invention's workflow controller diagram. The viewing and editing of complete input data and analyzing intermediate results is supported at each step of workflow controller execution. After market run completion, the complete workspace is stored and can be retrieved from archive at any later time.
- the execution is organized in pre-defined orders of steps performed by the workflow controller. This is a novel implementation not otherwise used or anticipated through any currently available market system.
- the market optimal clearing is organized into two iteration processes: Security Constrained Unit Commitment (SCUC) and Network Analysis (NA) iteration loop, and nested Security Constrained Economic Dispatch (SCED) and Network Analysis (NA) iteration loop.
- SCUC-NA iteration loop is executed until the transmission system feasibility and market clearing optimality is achieved.
- the SCED-NA iteration loop is entered only if transmission system feasibility is achieved to consider network nonlinearities and improve resource dispatch quality. As the final outcome of market clearing represent optimal resource commitments, energy and ancillary service awards without transmission line overloads.
- the SCUC engine determines resource commitment statuses and energy and ancillary service awards in optimal manner maximizing economic efficiency of overall electricity market.
- the energy and ancillary service are co-optimized and transmission congestion costs are minimized.
- the market energy supply and demand are balanced and regional ancillary services requirements are satisfied within transmission line power flow limits.
- Resource constructive and physical characteristics are considered to provide high operational quality of cycling and dispatches.
- the import, export, point-to-point, and virtual energy transactions are scheduled in optimal manner as well.
- the SCED engine determines optimal energy and ancillary service awards respecting resource commitments determined by the SCUC engine.
- the energy and ancillary service are co-optimized and transmission congestion costs are minimized.
- the market energy supply and demand are balanced and reginal ancillary services requirements satisfied without transmission line overloads.
- Detailed resource constructive and physical characteristics are considered to provide high operational quality of cycling and dispatches.
- the import, export, point-to-point and virtual energy transactions are scheduled in an optimal manner as well.
- the convergence tolerances are tightened to improve numerical accuracy and operational quality of resource dispatches.
- An NA engine embedded within both of the SCUC NA and SCED NA loops performs base case power flow calculations for given energy generations and consumptions determined by SCUC and SCED engines.
- the AC power flow model is used and a fast-decoupled solution methodology deployed.
- the slack power distribution is performed in proportion to the ratio of loss factor and clearing price to be aligned with optimization objective of SCUC and SCED engines.
- the base case transmission line power flows are calculated and highly loaded transmission lines are selected to be considered by SCUC and SCED engines.
- the base case transmission line constraints are formulated in incremental linearized form.
- the SCUC NA and SCED NA loops performs analysis of a number of contingencies to determine impacts on base case power flows.
- the DC power flow model is used and incremental solution methodology deployed. A variety of single and multiple generation and transmission line contingencies are considered.
- the transmission line contingency power flows are calculated and highly loaded transmission lines are selected to be considered by SCUC and SCED engines. Only a number of worst transmission line contingency power flows are selected.
- the contingency transmission constraints are formulated in the same incremental linearized form as base case transmission constraints.
- the final solution of electricity market clearing presents the optimal energy and ancillary service awards that maximize overall market economic efficiency and provides system operation reliability.
- the market clearing prices for awarded energy and ancillary service quantities are determined by the pricing engine.
- the pricing engine is designed considering the fundamental principles of competitive market economy: economic efficiency, participation rationality, incentive compatibility, price transparency, and budget balance.
- the market economic efficiency is provided by market commodity clearing performed by SCUC and SCED engines, while participation rationality, incentive compatibility, price transparency and budget balance are design objectives for the pricing engine.
- the common policy for electricity markets is marginal price formation mechanism that cannot be incentive compatible and it remains to be subject of market power mitigation measures.
- a variety of configurable price formation mechanisms for marginal market clearing prices is provided for awarded energy and ancillary service quantities.
- the pricing engine is configurable to perform the following pricing schemas:
- FIG. 1 is a diagram illustrating the platform architecture and data transfers of the designed system.
- FIG. 2 is a diagram illustrating the designed system operation and study workspaces, and save case management and archival.
- FIG. 3 is a diagram illustrating a system solution sequence tree.
- this disclosure is directed toward the next generation of electricity market systems that accommodate the advances of the existing electricity market platforms enhanced to deploy the latest developments in smart grid and distributed generation equipment, information technology, auction design theory and optimization algorithms.
- These advances of electricity market systems support evolutionary development of energy policy, market design rules, business models, and operation practices.
- FIG. 2 is a diagram illustrating the system's workspace provides complete recording of current operation 200 and archival of historical information 201 .
- the operation and study workspaces are maintained by save case mechanism 204 to support controllable electricity market operation, auditing re-runs and study analysis.
- the system deploys the state-of-the-art technology of graphical user interface that provides situation awareness, execution controllability and information usability of electricity market clearing and pricing processes. This process is shown in FIG. 1 .
- the display information contents, presentation formats and man-machine interaction of system provide easy, efficient and robust system operation.
- the system comprises a variety of configuration parameters, including but not necessarily limited to, resource parameters 101 , network model 102 , generic constraints 103 , contingency list 104 , outages 105 , AS Requirements 106 , AS regions 107 , Load Zones 108 , Hubs 109 , Settlement Points 110 , Load Distribution Factors 111 , and EMS data 112 as well as an interface with a Market Participant Portal 118 that gathers energy bid/offer 113 , virtual and financial bids and offers 114 , self-schedule 115 , AS Offers 116 , and Interchange Transaction 117 data to be able to support operation of the existing electricity markets as well as support advances into the next stage of electricity industry restructuring.
- the manual/automatic execution options, market commodity activation 136 , market type selection and timeline configuration provide settings appropriate for a variety of electricity market arrangements.
- the features and alternative models can be selected according to objectives of system operation and analysis.
- the thresholds, tolerances and optimization parameters are enterable to provide adequate accuracy and performances.
- the system may also provide functionality for saving cases 123 and various historical data 125 known in the art.
- Other embodiments of the system may also comprise of functionality to facilitate the export of invoices 128 .
- the system considers a variety of energy generation and consumption resources with detailed representation of their operating capabilities.
- a variety of intermittent generating resources (solar, wind, biomass, geothermal) are considered.
- the complexity of operation of joint owned units, energy storage resources and combined cycle plants are represented into details in optimization mathematical models.
- the dispatchable and interruptible load resources are considered as well.
- the generation costs are presented with three-part energy offers, while consumption benefits are presented by three-part bids.
- the offer and bid price curves can be step-wise or piece wise linear functions.
- Non-resource specific trading is supported by the system to accommodate competitive and reliable arrangements for import, export, point-to-point and virtual transaction 113 , 114 .
- a point of delivery and point of receive can be any settlement point type (pricing node, load zone 108 , trading hub 109 ).
- a variety of ancillary service types and product characteristics can be procured in system 106 , 107 , 116 .
- the procurement of regulation up, regulation down, spinning reserve, and supplemental online and offline reserves is supported.
- Regional ancillary service requirements are enforced and ancillary service substitution is accommodated where higher quality ancillary services can be used instead of lower quality ancillary services.
- Ancillary service substitution mechanism is configurable to support regulation up, spinning reserve and supplemental online reserve cascading.
- the regulation up can be used instead of spinning reserve and supplemental online reserve, while spinning reserve can be used instead of supplemental online reserve.
- the execution of the system is facilitated by a work flow controller as illustrated by FIG. 4 and supported by workspaces FIG. 2 and solution sequence trees FIG. 3 .
- the execution of workflow controller creates a branch on the solution sequence tree.
- the workflow controller represents a strategy and methodology to achieve the optimal outcomes of electricity market clearing and pricing.
- Execution of workflow is directly configurable by breakers located between execution boxes representing calculation engines.
- the breaker setting can be changed at any time and execution of workflow controller stops at first open breaker according to the execution diagram. At the stop point, both input data and output results of any executed calculation box can be reviewed and edited.
- the calculation box can be re-executed at any stopping point and the solution sequence can continue to the next open breaker.
- the final solution is selected by the operator.
- the workflow controller facilitates execution of the following calculation boxes:
- the system workflow controller process comprises the execution of SCUC-NA iteration loop 403 to determine feasible and optimal resource commitments and energy and ancillary service awards.
- the feasibility test verifies transmission line power flow limits while the optimality test verifies change of optimization objective in respect to the convergence tolerance.
- the search for optimal solution beyond feasibility of transmission constraints represents a novel approach enabled by high performances of SCUC 137 engine.
- the SCUC-NA iteration loop 403 process is completed if the optimal solution is achieved or the maximal number of iterations is reached.
- the system workflow controller process also comprises the execution of nested SCED-NA iteration loop 404 to determine feasible and optimal energy and ancillary service awards for optimal resource commitments determined by the SCUC engine 137 .
- the SCED-NA iteration loop 404 is entered when SCUC-NA iteration process 403 achieves a feasible solution.
- the main purpose of SCED-NA iteration process 404 is to address nonlinearity of AC power flow model without re-commitment of resources. Also, some features can be activated in SCED-NA loop 404 only and tighter optimality tolerances can be used. As a consequence, the optimal solution can be achieved in shorter time and the operational quality of the optimal solution can be improved.
- the feasibility test verifies transmission line power flow limits while optimality test verifies change of optimization objective as well.
- the SCED-NA iteration process 404 is completed if the optimal solution is achieved or the maximal number of iterations is reached.
- the invention comprises the SCUC 137 and SCED 138 engines to optimize resource commitments and energy and ancillary service awarded quantities that balance market commodity supply and demand, satisfies reginal ancillary service requirements 106 respecting transmission constraints and resource operational capabilities.
- Both SCUC 137 and SCED 138 engines comprise two-step deployment of optimization solvers:
- the system comprises the Pricing Engine 140 to determine settlement prices for awarded quantities of market commodities.
- the pricing schema can be configured to perform dispatching, relaxed, partial commitment and advanced price formation.
- the Quadratic Programming solver is deployed to determine shadow prices for market power balance, regional ancillary service requirements and transmission constraints. These shadow prices are used as determinants to calculate marginal settlement prices for awarded energy and ancillary service quantities.
- the SCUC 137 , SCED 138 and Pricing 140 Engines of the system comprise tight mathematical formulations of resource constructive and physical characteristics without approximations and aggregations.
- the novel operational models are tightened to the strongest possible level using convex hull mathematical constructs, as follows:
- the invention comprises a system and method for determining market commodity clearing utilizing an objective function for the optimization objective of the inventive system to represent the economic efficiency of overall market operation in each market environment.
- objective functions are configurable depending on the specific market environment and may be comprised of elements such as energy consumption benefits and interruption costs of load entities, commitment costs and energy production costs of generation entities, ancillary service costs for both load and generation entities, offer costs for energy selling transactions, bid benefits for energy buying transactions, and penalties for system power imbalance, ancillary service scarcity and transmission line overloads.
- the optimization objective is the maximization of economic efficiency of overall market operation that, for certain embodiments, may be presented in the following mathematical form:
- the invention may further comprise systems and methods to model and utilize energy offers and bids.
- Energy offers represent minimal prices to sell energy for physical deliveries or virtual trades.
- An energy offer price curve can be non-decreasing stepwise or piecewise linear curve with up to ten segments that are optimized by a Quadratic Programing solver.
- the piecewise linear energy offer price curves are approximated as stepwise price curves to be optimized by a linear Mixed Integer Linear Programing solver.
- P offer ⁇ seg ⁇ P seg offer ; 0 ⁇ P seg offer ⁇ P seg max
- energy offer cost curves can be presented in the form:
- EOC offer ⁇ seg ⁇ ( a seg offer + EOP seg offer ⁇ P seg offer ) for piecewise linear cost curve, or
- EOC offer ⁇ seg ⁇ ( a seg offer + b seg offer ⁇ P seg offer + 0.5 ⁇ EOC seg offer ⁇ ( P seg offer ) 2 ) for piecewise quadratic cost curve.
- Energy bids represent a maximal price to buy energy for physical consumption or virtual trading.
- An energy bid price curve can be non-increasing stepwise or piecewise linear curve with up to ten segments that are optimized by a Quadratic Programing solver.
- the piecewise linear energy bid price curves may be approximated as stepwise price curves to be optimized by a linear Mixed Integer Linear Programing solver.
- energy bid benefit curves can be presented in the form:
- EBB bid ⁇ seg ⁇ ( a seg bid + EOP seg bid ⁇ P seg bid ) for piecewise linear energy bid benefit curve, or
- EBB bid ⁇ seg ⁇ ( a seg bid + b seg bid ⁇ P seg bid + 0.5 ⁇ EOP seg bid ⁇ ( P seg bid ) 2 ) for piecewise quadratic energy bid benefit curve.
- Energy transactions can be specified in a variety of ways depending on trade arrangements.
- Various embodiments of the inventive systems and methods may utilize any of such transactions known in the art, including but not limited to self-scheduled transactions (import, export, wheeling, point-to-point transactions) submitted as fixed MW schedules which are treated as price takers; fixed transactions (import offers, export bids, up-to-congestion wheeling and point-to-point transactions) submitted as fixed MW quantity to be scheduled or not as whole are treated as interruptible transactions; flexible transactions (import offers, export bids, up-to-congestion wheeling and point-to-point transactions) submitted as priced variable quantity are scheduled in an optimal manner; or time-block transactions (import offers, export bids, up-to-congestion wheeling and point-to-point transactions) submitted as fixed or variable quantity that are scheduled at the same MW level across pre-specified block of time intervals.
- the invention may further comprise system and methods to model and utilize startup cost offers.
- the startup cost offers represent stepwise non-decreasing functions of resource cooling time.
- Startup costs are typically offered for hot, warm and cold resource warmth state.
- the hot-to-warm and warm-to-cold transition times represent resource registered parameters. As a resource can be only in one warmth state at any time interval, only time intervals when a resource starts up are of interest.
- One embodiment of the inventive system and methods utilizes models created with the understanding that a resource is in hot state only if unit is shutdown at one of the last few time intervals before startup.
- Embodiments may also utilize models created with the understanding that a resource is in warm state only if unit is shutdown in-between hot and cold time intervals before startup.
- the minimization of increasing startup cost function may then select warmth state with the lowest costs according to above understanding of constraints.
- the price for a minimum energy block may be submitted as separate value.
- the no-load cost can be submitted instead when the first segment of energy offer curve should be extended to zero MW.
- the invention may further comprise systems and methods to model and utilize ancillary service offers.
- Ancillary service offers represent non-decreasing stepwise price curves of up to five segments, but typically of a single segment.
- a separate offer is submitted for each ancillary service type (Regulation Up, Regulation Down, Spinning Reserve and Supplemental Reserve).
- variable may be:
- AS offer ⁇ seg ⁇ AS seg offer ; 0 ⁇ AS seg offer ⁇ AS seg max
- ancillary service offer cost curves can be presented in linear form for each segment:
- ASC offer ⁇ seg ⁇ ( a seg offer + ASP seg offer ⁇ AS seg offer ) .
- the system power balance is a significant operational requirement in all market environments.
- One particular embodiment of the invention may comprise systems and methods can express system power balance as balance of the total system generation and the total system consumption including network energy losses. These terms have different expressions in different market environments.
- the total awarded energy offers to sell energy must be balanced with the total awarded energy bids to buy energy plus network energy losses, i.e. awarded energy bids represent delivered energy, as follows:
- P sys loss ⁇ ( P node t ) P loss NA ; t + ⁇ node ⁇ N ⁇ ⁇ node t ⁇ ( P node t - P node NA ; t ) ; t ⁇ T
- P node t ⁇ g ⁇ node ⁇ P g t + ⁇ v ⁇ node v ⁇ VO ⁇ P v t + ⁇ w ⁇ node w ⁇ WO ⁇ P w t - ⁇ l ⁇ node ⁇ P l t - ⁇ v ⁇ node v ⁇ VB ⁇ P v t - ⁇ w ⁇ node w ⁇ WB ⁇ P w t ; node ⁇ N ; t ⁇ T
- the Network Analysis determines incremental loss factors ⁇ node t , system losses loss P loss NA;t and nodal power injections P node NA;t .
- the total energy generation must be balanced with load resource consumption including non-conforming load schedules and system load forecast adjusted by energy net interchange.
- the network energy losses are incorporated into system load forecast; i.e. only incremental changes of losses due to resource commitments and re-dispatch are considered, as follows:
- ⁇ ⁇ ⁇ P sys loss ⁇ ( P node t ) ⁇ node ⁇ N ⁇ ⁇ node t ⁇ ( P node t - P node NA ; t ) ; t ⁇ T .
- P node t ⁇ g ⁇ node ⁇ ⁇ P g t ; ⁇ node ⁇ N ; t ⁇ T .
- the invention may further comprise systems and methods to model and utilize ancillary service requirements.
- the ancillary service procurement may be accommodated in day-ahead and real-time market timeline domains, while in Reliability Unit Commitment application the awarded ancillary service commodities are preserved.
- the ancillary service requirements are enforced for each ancillary service region and each ancillary service type for each time interval. Any qualified generation and load resource can provide ancillary service.
- the ancillary service requirements are enforced in a cascading manner, i.e. not awarded ancillary service offers for a higher ancillary service quality can be used for lower ancillary service quality.
- ancillary service substitution is performed in the following ancillary service quality order: regulation up can be used for both spinning reserve and supplemental reserves and spinning reserve can be used for supplemental reserve.
- the ancillary service substitution mechanism is configurable and, in some embodiments, may not be allowed. Some embodiments of the described system and methods may accommodate substitution by formulating the ancillary service requirements as follows:
- the active and reactive AC power flows for transmission lines, transformers and phase shifters can be expressed in the following unified form:
- the transmission line power flows may then be represented in incremental linearized form in respect to base case and contingency line power flows that are determined by Network Analysis:
- F line t F line NA ; t + ⁇ node ⁇ N ⁇ ⁇ PTDF line node ⁇ ( P node t - P node NA ; t ) ⁇ F line max ; t
- P node t ⁇ g ⁇ node ⁇ ⁇ P g t + ⁇ v ⁇ node v ⁇ VO ⁇ ⁇ P v t + ⁇ w ⁇ node w ⁇ WO ⁇ ⁇ P w t - ⁇ l ⁇ node ⁇ ⁇ P l t - ⁇ v ⁇ node v ⁇ VB ⁇ ⁇ P v t - ⁇ w ⁇ node w ⁇ WB ⁇ ⁇ P w t ; ⁇ node ⁇ N ; t ⁇ T .
- the full resource operating range i.e. operating limits
- the full resource operating range are considered for energy and ancillary services within some embodiments of the current system and methods as: u g t ⁇ P g OpMin;t ⁇ P g t ⁇ RegDn g t ⁇ u g t ⁇ P g OpMax;t ; g ⁇ G; t ⁇ T u g t ⁇ P g OpMin;t ⁇ P g t +RegUp g t +SpinRes g t +SuplRes g t ⁇ u g t ⁇ P g OpMax;t ; g ⁇ G; t ⁇ T
- the invention may further comprise systems and methods to model and utilize resource ancillary service limits.
- the Regulation Reserve procurement is limited by regulating ramp rates and Regulation Reserve time domain: RegDn g t ⁇ RR g RegDn ⁇ T dom Reg ; g ⁇ G; t ⁇ T RegUp g t ⁇ RR g RegUp ⁇ T dom Reg ; g ⁇ G; t ⁇ T.
- the Spinning Reserve is limited by emergency ramp rate and Spinning Reserve time domain: SpinRes g t ⁇ RR g Emr ⁇ T dom Spin ; g ⁇ G; t ⁇ T
- Some embodiments may utilize a self-commitment constraint.
- the resource self-commitment status may violate resource inter-temporal constraints, i.e. for self-committed time intervals resource inter-temporal constraints are not enforced.
- Some embodiments may utilize resource initial and final conditions.
- Resource initial conditions are derived from commitment history and resource operation projection till beginning of time period.
- a startup time function represents stepwise non-decreasing function of cooling time. Startup time may be specified for hot, warm and cold resource warmth state. The hot-to-warm and warm-to-cold transition times for start time function are the same as for startup cost function.
- the startup time is considered at the beginning of time period in conjunction with resource notification time. If a resource cannot be notified on time to be started then that resource is treated offline at the beginning of time period.
- the invention may further comprise systems and methods to model and utilize resource ramping limits. For resources that can ramp with a constant upward or downward ramp rate across its operating range, the constant ramping limits are enforced.
- the dynamic ramping limits are enforced.
- the ramp rates can be general stepwise functions of resource operating points. Break points for both upward and downward ramp rate functions are the same.
- the invention may further comprise systems and methods to model and utilize joint owned units.
- the joint owned units can submit cumulative or separate offers for each share. If cumulative offer is submitted than joint owned unit is processed as regular generation resource.
- Joint owned unit share awards are limited to ownership percentage of physical JOU capability if ownership information is provided: P share t ⁇ p share ⁇ P JOU max
- Each combined cycle plant configuration is treated as separate generating resource. If a combined cycle unit within a configuration is not available then alternate combined cycle unit is considered.
- a status, startup, shutdown and an auxiliary variable are introduced for each configuration of combined cycle plant.
- the combined cycle plant configuration status, startup and shout down variables are defined in the same way as for any other generation resource.
- the combined cycle plant configuration startup variables for a configuration are determined by possible transitions from one configuration into another configuration.
- Possible transitions are defined by combined cycle plant transition matrix.
- a commitment constraint is added to enforce combined cycle plant operation only in one configuration including combined cycle plant offline mode in any time interval:
- the inter-temporal constraints can be enforced for each combined cycle plant configuration individually in the same way as for standard generation resources.
- the minimum down time constraints are considered only for all OFF configurations, i.e. when whole plant is offline.
- the energy and ancillary service offers are configuration based within certain embodiments of the inventive system and method. It is not necessary that offers are submitted for all registered combined cycle plant configurations. Only configurations with submitted offers are considered in optimization according to connectivity of their transitions. The offline supplemental reserve can considered only for all OFF configurations. The energy and ancillary service offer costs are incorporated into optimization objective.
- the augmented combined cycle plant states can be treated as separate combined cycle plant configurations or as extension of operating range of the existing configurations (typically with higher energy offer prices). Augmented configurations and correspondent combined cycle units are registered as separate resources.
- the energy awards for combined cycle plant configurations are distributed to physical combined cycle units in proportion of submitted weighted distribution factors. If aggregation factors are not submitted then distribution factors are based on combined cycle unit capacities.
- the invention may further comprise systems and methods to model and utilize intermittent generation resources.
- the intermittent generation resources can submit energy and ancillary service offers as any other generation resource using the systems methods of the invention.
- the intermittent generation resources are treated always online without ramping limitations.
- the power output and ancillary service awards of intermittent generation resources are limited by forecasted wind power potential, i.e.
- the intermittent generation resource cannot be deployed above available power level: P g OpMin;t ⁇ P g t ⁇ RegDn g t ⁇ P g WPP;t ; g ⁇ IGR; t ⁇ T P g OpMin;t ⁇ P g t +RegUp g t +SpinRes g t +SuplRes g t ⁇ P g WPP;t ; g ⁇ IGR; t ⁇ T.
- the intermittent generation resources can be aggregated within a wind or solar farm if the farm has only one point of interconnection. If farm includes firming storage devices controlled remotely then the farm can be treated as an energy storage resource.
- the invention may further comprise systems and methods to model and utilize energy storage resources where the energy storage resources are considered to operate in three states: charging, offline, and discharging.
- the dynamics of energy storage resource charging and discharging processes can vary from seconds, minutes, hours and days to even seasons and years.
- the energy storage resources with notification times and inter-temporal parameters comparable with market timeline will be considered.
- the duration limited energy storage resources can cycle with negligible periodicity and they can be treated as online resources that can cycle continuously between charging and discharging operating modes. These resources can be dispatched from zero MW to maximum power in both charging and discharging directions.
- the systems and methods support the energy storage resources submitting three-part energy bids for charging energy and three-part energy offers for discharging energy.
- These bids and offers may include single value transition costs, minimum energy costs and incremental energy price curves for both charging and discharging operating modes.
- the energy storage resources can provide online ancillary services in both charging and discharging operating modes.
- the offline Supplemental Reserve can be provided in offline operating mode only. Appropriate ancillary service offers can be submitted. It is assumed that starred energy is always sufficient to delivery awarded ancillary service.
- a status, startup and shutdown variables are defined for both charging and discharging modes as known in the art. Also, resource charging/discharging power limits and inter-temporal constraints for both charging and discharging modes are enforced as usually.
- the specifics for energy storage resources consists of energy storage capability.
- the systems and methods network can support different locations of charging load and discharging generation.
- the operation of energy storage resource is determined by prices at different time intervals and prices at different network nodes.
- the system dispatch can dispatch energy storage resource optimally with guarantied positive benefits even if charging bid and discharging offer is not submitted.
- the invention may further comprise systems and methods to model and utilize demand response resources where such demand resources are treated as price driven reduction of consumption in respect to the base load.
- Typical demand response resources represent a site where a behind the meter generating resource is located.
- P l t P BL t ⁇ P g t ; l,g ⁇ DR; t ⁇ T
- the effective load of demand response resources are considered, i.e. the base load of demand resource is netted with awarded generation part of demand resource.
- the invention may further comprise systems and methods to model and utilize load resources.
- a physical load resource can participate in electricity market symmetrically to generating resources utilizing the inventive systems and methods.
- This load resource can submit three-part bid for load curtailment and price sensitive dispatch.
- the three-part bid may include curtailment costs, interruption costs and energy price curve.
- curtailed operating mode there is no consumption. While in dispatchable operating mode, load can be dispatched between load resource operating minimum and maximum.
- a binary variable is introduced within the inventive systems and methods to indicate curtailed or dispatchable operating mode. Also, variables for transitions between operating modes (load interruption variable and curtailment end variable) are introduced in symmetrical way as status, startup and shutdown variables for generation resource.
- the invention may further comprise systems and methods to model and utilize the following load resource inter-temporal constraints represented according to any known method known in the art:
- Some embodiments may also utilize resource operating limits where the operating limits are enforced for interruptible load resource: u l t ⁇ P l OpMin;t ⁇ P l t +RegDn l t ⁇ u l t ⁇ P l OpMax;t ; l ⁇ ILR; t ⁇ T u l t ⁇ P l OpMin;t ⁇ P l t ⁇ RegUp l t ⁇ SpinRes l t ⁇ SuplRes l t ⁇ u l t ⁇ P l OpMax;t ; l ⁇ ILR; t ⁇ T.
- the invention comprises a system and method for determining market commodity pricing.
- the main features of competitive electricity market are efficient market clearing and competitive price formation.
- the economic efficiency of market clearing is provided within the inventive systems and methods by utilizing optimal resource commitments and optimal awarded quantities for energy and ancillary service commodities determined by system clearing.
- the price formation mechanism of the present invention will determine settlement prices for awarded market commodities along with the following desired properties:
- Incentive capability i.e. the best strategy for each market participant is truthful submission of offers and bids.
- Transparency i.e. settlement prices are unanimous; not resource specific.
- a marginal cost based price formation mechanism for electricity market commodities is designed to support a variety of existing pricing policies and minimize violations of above pricing principles.
- the proposed pricing schema of the described invention fulfills thee above price formation criteria (except incentive compatibility) within variety of electricity market environments.
- the omission of incentive compatibility is due to design impossibility and remains the subject for market power mitigation measures known in the art.
- the main problem of price formation in electricity market is the determination of marginal settlement prices for fixed market commodities, which is mathematically impossible.
- the system pricing schema represents a variety of price formation mechanisms that deploy a Quadratic Programming optimization solver to calculate shadow prices for system requirements (system power balance and ancillary service reginal requirements) and shadow prices for transmission constraints. Different settings are needed for different pricing schema types, as follows below.
- the optional feature selection and dispatch range settings can accommodate all existing pricing schemas as well invented advanced pricing schema.
- a setting is possible where out-of-market payments to guaranty cost recovery and incentivize market commodity awards as well (recommended).
- Some embodiments of the invention may comprise settings attuned to a time interval independency.
- the optimal awards for market commodities incorporate all interdependencies of time intervals, like ramping constraints, inter-temporal constraints, daily energy limits.
- the settlement prices for awarded market commodities are determined for each time interval separately within the ordered structure of the systems and methods of the disclosed invention. It is assumed that the optimal schedules for awarded market commodities will be followed in real-time.
- the optimal awards for market commodities for previous time interval are treated as starting point to determine settlement prices for the current time interval. All ramping and inter-temporal constraints are built into resource dispatch limits for the current time interval. Also, impacts of resource initial conditions and uneconomic pre-ramping are eliminated.
- the Pricing Engine solves a set of independent single-interval optimization problems to determine settlement prices for all time intervals within market time period.
- Not committed resources are (not) eligible to set settlement prices
- committed minimum energy blocks are (not) eligible to set settlement prices
- minimum energy blocks for lumpy fast-start resources are/not eligible to set price
- pre-ramped resources are (not) eligible to set settlement prices
- interruptible load resources are/not eligible to set settlement prices
- fixed transactions are (not) eligible to set settlement prices
- time-block transactions are (not) eligible to set settlement prices.
- the settlement prices for ancillary services are determined by ancillary service offers in conjunction to energy lost opportunity costs, while ancillary service self-procurements are treated as price takers.
- the invention may further comprise systems and methods to model settings for a dispatching pricing schema where all committed dispatchable resources, i.e. only offers and bids for flexible market commodities, are eligible to set market clearing prices.
- An embodiment of the invention with a dispatching pricing schema price formation mechanisms comprises of the following steps: fix resource commitment statuses at optimal values, enforce ramping up and down limits (optional), execute Quadratic Programming optimization solver, calculate Locational Marginal Prices and their energy, loss and congestion components, and calculate regional ancillary service settlement prices.
- Fixed market commodities are treated as price takers, i.e. they are treated as free market commodities. This price formation mechanism depress the market clearing prices across system resulting in underpriced fixed market commodities. These settlement prices are not individually rational and they cause market budget deficit.
- the invention may further comprise systems and methods to model settings for a relaxed pricing schema where eligible committed resources, i.e. offers and bids for both fixed and flexible market commodities, can set market clearing prices.
- An embodiment of the invention with a relaxed pricing schema price formation mechanisms comprises of the following steps: Relax committed minimum energy blocks to be dispatchable anywhere between zero MW and operating minimum, adjust offer price for minimum energy block to incorporate no load costs and a share of startup costs, convexify extended energy offer curve over full dispatchable range from zero MW to operating maximum, enforce resource ramping up and down limits (optional), execute Quadratic Programming optimization solver, calculate Locational Marginal Prices and their energy, loss and congestion components, and calculate regional ancillary service settlement prices.
- fixed market commodities are made flexible and able to set settlement prices.
- the system dispatch is hypothetical and settlement prices do not reflect actual operating costs and benefits. Still, this price formation mechanism is not individually rational nor budget balanced.
- the invention may further comprise systems and methods to model settings for a partial commitment pricing schema where resource commitment statuses are continuous variables relaxed between zero and one to enable both fixed and flexible market commodities to set market clearing prices.
- An embodiment of the invention with a partial commitment pricing schema price formation mechanisms comprises of the following steps: relax resource commitment status binary variable to be continuous between zero and one, enforce resource ramping up and down limits (optional), execute Quadratic Programming optimization solver, calculate Locational Marginal Prices and their energy, loss and congestion components, and calculate regional ancillary service settlement prices.
- the invention may further comprise systems and methods to model settings for an advanced pricing schema where the eligible committed resources, i.e. offers and bids for both fixed and flexible market commodities, can set market clearing prices while resource dispatch points are preserved.
- An embodiment of the invention with an advanced pricing schema price formation mechanisms comprises of the following steps: relax committed minimum energy blocks to be dispatchable anywhere between zero MW and operating minimum, adjust offer price for minimum energy block to incorporate no load costs and a share of startup costs, enforce resource ramping up and down limits (optional), set narrow limits around awarded incremental energy to be dispatchable only in that range, execute Quadratic Programming optimization solver, calculate Locational Marginal Prices and their energy, loss and congestion components, and calculate regional ancillary service settlement prices.
- the most expensive units of awarded market commodities determine settlement prices. To discover these marginal market commodity prices, fixed market commodities are made flexible and able to set settlement prices, but awards for flexible market commodities are preserved by narrow dispatch limits. The system dispatch is preserved and settlement prices reflect actual operating costs and benefits at awarded values of market commodities.
- the advanced price formation mechanism is individually rational and budget balanced without out-of-market subsidy.
- a marginal costs based pricing schema is designed to support a variety of existing pricing policies and minimize violations of above pricing principles. It is possible to arrange settings of the proposed system advanced pricing schema to satisfy all above criteria except incentive compatibility. This omission is subject to market power mitigation measures.
- the locational marginal prices are calculated in standard way when determining settlement price calculation; using shadow prices for system power balance and transmission line constraints, as follows:
- LMP node t ⁇ sys t - ⁇ sys t ⁇ ⁇ nnode t + ⁇ line ⁇ N ⁇ ⁇ PTDF line node ⁇ ⁇ line t
- the locational marginal prices fully reflect startup, no-load/minimum energy costs of committed resources in variety of manner.
- the calculated locational marginal prices represent settlement prices for energy that consist of three price components:
- P over t is system over generation at time interval t
Abstract
Description
-
- a) Dispatching pricing schema where only flexible market commodities are priced
- b) Relaxed pricing schema where fixed market commodities are relaxed to be able to set clearing prices in a hypothetical system dispatch
- c) Partial commitment pricing schema where resource commitments are relaxed to be able to set clearing prices allowing fractional resource commitments, and
- d) Advanced pricing schema where both fixed and flexible market commodities can set clearing prices preventing awarded energy and ancillary service quantities.
The pricing engine can be executed in a variety of configurations and resulting clearing prices can be analyzed and compared.
-
- 1. Topology Processor determines network topology based on nominal breaker statuses and
transmission equipment outages 401. - 2. Pre-Processor validates existence, interdependencies and consistency of
input market data 402. - 3.
SCUC engine 137 determines optimal resource commitments and energy and ancillary service awards maximizing market economic efficiency through SCUC-NA loop 403. - 4.
SCED engine 138 determines optimal energy and ancillary service awarded quantities for optimal resource commitments determine bySCUC engine 137 maximizing marketeconomic efficiency 404. - 5.
NA engine 133 calculatesbase case 134 andcontingencies 135 power flows and formulates transmission constraints within SCUC-NA loop 403 and SCED-NA loop 404. - 6. Pricing engine calculates settlement prices for awarded quantities of
market commodities 413. - 7. Post-Processing validate and delivers approved outcomes of market commodity clearing and pricing to
downstream systems 414.
- 1. Topology Processor determines network topology based on nominal breaker statuses and
-
- 1.Mixed Integer Linear Programming solver is deployed to optimize binary variables using linear approximations of submitted energy price curves.
- 2. Quadratic Programming solver is deployed to optimize continuous variables for the optimal values of binary variables and using originally submitted piecewise linear energy price curves.
-
- a) The resource status, startup and shutdown binary variables are formulated using convex combinations of vertex points that represent physically possible states.
- b) Resource operating and regulating ranges are formulated using disjunctive region constructs.
- c) Static ramping limits are represented as tight constraints comprising resource status, startup and shut down variables as well as resource power outputs in two subsequent time intervals.
- d) Dynamic ramping limits are represented as tight constraints comprising different ramp rates in a number of segments within resource power output range.
- e) Resource startup cost functions are modeled for hot, warm, and cold warmth states using warmth state variables.
- f) Resource minimum up and down times are formulated in tightest possible form.
- g) Commitment model for joint owned units enforces simultaneous commitments for joint owned unit shares.
- h) Dynamic model for energy storage resources considers storage capacities and charging/discharging resource cycling.
- i) Multi-state model of combined cycle plant operation considers configuration transition matrix and transition times.
for piecewise linear cost curve, or
for piecewise quadratic cost curve.
for piecewise linear energy bid benefit curve, or
for piecewise quadratic energy bid benefit curve.
SUCt =h t·SUCt h +w t·SUCt w +c t·SUCt c
for transmission lines
αj;i=1; Bi;j sh=0
σi;j=σj;i=0
for transformers, and
αj;i=1; Bi;j sh=0
σj;i=0
for phase shifters.
Pg EcoMin;t≤Pg t≤Pg EcoMax;t; g ∈ G; t ∈ T
u g t ·P g OpMin;t ≤P g t−RegDng t ≤u g t ·P g OpMax;t ; g ∈ G; t ∈ T
u g t ·P g OpMin;t ≤P g t+RegUpg t+SpinResg t+SuplResg t ≤u g t ·P g OpMax;t ; g ∈ G; t ∈ T
P g OpRegMin;t ≤P g t−RegDng t ; g ∈ G; t ∈ T
P g t+RegUpg t ≤P g OpRegMax;t ; g ∈ G; t ∈ T
kg t≤ug t
RegDng t+RegUpg t ≤k g t·(P g RegMax;t −P g RegMin;t); g ∈ G; t ∈ T
RegDng t ≤RR g RegDn ·T dom Reg ; g ∈ G; t ∈ T
RegUpg t ≤RR g RegUp ·T dom Reg ; g ∈ G; t ∈ T.
SpinResg t ≤RR g Emr ·T dom Spin ; g ∈ G; t ∈ T
SuplONResg t ≤u g t ·RR g Normal ·T dom Supl ; g ∈ G; t ∈ T.
SuplOFFResg t ≤q g t ·RR g Normal·(T dom Supl −T g StartTime)
q g t +u g t≤1; g ∈ G; t ∈ T
-
- Minimum up time constraints
- Maximum up time constraints
- Minimum down time constraints
- Maximum number of starts constraints
ushare1 t=ushare2 t= . . . =ushareN t; share ∈ JOU
P share t ≤p share ·P JOU max
P j t ≥t j;c up;t ·P max;j t j ∈ c up
P j t ≤t c;j dn;t ·P min;c t j ∈ c dn
P g OpMin;t ≤P g t−RegDng t ≤P g WPP;t ; g ∈ IGR; t ∈ T
P g OpMin;t ≤P g t+RegUpg t+SpinResg t+SuplResg t ≤P g WPP;t ; g ∈ IGR; t ∈ T.
SESP t=0=SESR 0; SESR t=T=SESR T
S ESR t+1=ηESR s ·S ESR t+ηESR c ·P ESR c;t−(1/ηESR d)·P ESR d;t ; t ∈ T
SESR min≤SESR t≤SESR max; t ∈ T
P l t =P BL t −P g t ; l,g ∈ DR; t ∈ T
-
- Minimum non-interruption time constraints
- Maximum interruption time constraints
- Maximum number of interruptions constraints
u l t ·P l OpMin;t ≤P l t+RegDnl t ≤u l t ·P l OpMax;t ; l ∈ ILR; t ∈ T
u l t ·P l OpMin;t ≤P l t−RegUpl t−SpinResl t−SuplResl t ≤u l t ·P l OpMax;t ; l ∈ ILR; t ∈ T.
To further clarify and describe the above notation used within the current application, the applicant provides the below Notation tables:
Variables
- ug t is status variable for generating unit g at time interval t
- sg t is startup variable for generating unit g at time interval t
- rg t is shutdown variable for generating unit g at time interval t
- kg t is regulation mode variable for generating unit g at time interval t
- ul t is status variable for load l at time interval t
- sl t is curtailment end variable for load l at time interval t
- rl t is curtailment start variable for load l at time interval t
- ht is resource hot state at time interval t
- wt is resource warm state at time interval t
- ct is resource cold state at time interval t
Commodities - Pg t is power output for generating unit g at time interval t
- Pl t is power consumption for load l at time interval t
- Pv t is power injection for virtual offer/bid v at time interval t
- Pw t is power injection for financial offer/bid w at time interval t
- ASg t is AS reserve for generating unit g at time interval t
- ASl t is AS reserve for load l at time interval t
- RegDnr t is Regulation Down for resource r at time interval t
- RegUpr t is Regulation Up for resource r at time interval t
- SpinResr t is Spinning Reserve for resource r at time interval t
- SuplResr t is Supplemental Reserve for resource r at time interval t
- Rr Up;t is ramping up service for resource r at time interval t
- Rr Dn;t is ramping down service for resource r at time interval t
- Tdom Reg is Regulation Reserve time domain
- Tdom Spin is Spinning Reserve time domain
- Tdom Supl is Supplemental Reserve time domain
Resource Parameters - Pg EcoMin;t is economic minimum for resource g at time interval t
- Pg EcoMax;t is economic maximum for resource g at time interval t
- Pg OpMin;t is operating minimum for resource g at time interval t
- Pg OpMax;t is operating maximum for resource g at time interval t
- Pg RegMin;t is regulating minimum for resource g at time interval t
- Pg RegMax;t is regulating maximum for resource g at time interval t
- RRg Dn is ramp rate down for resource g
- RRg Up is ramp rate up for resource g
- Tramp is ramping time
Costs/Benefits - EBmarket total is total market Economic Benefit
- SUCg t(⋅) is Start Up Cost for generating unit g at time interval t
- SUCt h is hot Start Up Cost at time interval t
- SUCt w is warm Start Up Cost at time interval t
- SUCt c is cold Start Up Cost at time interval t
- MECg t is Minimum Energy Cost for generating unit g at time interval t
- EOPg t(⋅) is Energy Offer Price for generating unit g at time interval t
- EOCg t(⋅) is Energy Offer Cost for generating unit g at time interval t
- ASPg t(⋅) is AS Price for generating unit g at time interval t
- ASCg t(⋅) is AS Cost for generating unit g at time interval t
- LICl t is Load Interruption Cost for load l at time interval t
- LCCl t is Load Curtailment Cost for load l at time interval t
- EBPl t(⋅) is Energy Bid Price for load l at time interval t
- EBBl t(⋅) is Energy Bid Benefit for load l at time interval t
- ASPl t(⋅) is AS Price for load l at time interval t
- ASCl t(⋅) is AS Cost for load l at time interval t
- EOPv t(⋅) is Energy Offer price for virtual trader v at time interval t
- EOCv t(⋅) is Energy Offer Cost for virtual trader v at time interval t
- EBPv t(⋅) is Energy Bid Price for virtual trader v at time interval t
- EBBv t(⋅) is Energy Bid Benefit for virtual trader v at time interval t
- EOPw t(⋅) is Energy Offer Price for financial trader w at time interval t
- EOCw t(⋅) is Energy Offer Cost for financial trader w at time interval t
- EBPw t(⋅) is Energy Bid Price for financial trader w at time interval t
- EBBw t(⋅) is Energy Bid Benefit for financial trader w at time interval t
Network Model - Pnode t is net power injection variable at network node at time interval t
- Pnode NA;t is calculated net power injection at network node at time interval t
- Psys loss(⋅) is network loss model
- Ploss NA;t is calculated network losses at time interval t
- αnode t is loss factor for network node at time interval t
- Fline t is active power flow for transmission line at time interval t
- Fline NA;t is calculated active power flow for transmission line at time interval t
- Fline max;t is maximal active power flow for transmission line at time interval t
- PTDFline node is shift factor for transmission line network node
Infeasibilities
- Punder t is system under generation at time interval t
- ASunder t is AS at time interval t
- Fline over;t is overload for transmission line at time interval t
Penalties - PBPover t(⋅) is over generation Power Balance Penalty at time interval t
- PBPunder t(⋅) is under generation Power Balance Penalty at time interval t
- ASPunder t(⋅) is AS insufficiency Penalty at time interval t
- TCPline over;t(⋅) is violation Transmission Constraint Penalty at time interval t
Sets - t ∈ T is time interval t within time period T
- g ∈ G is generating unit g within generation fleet G
- l ∈ L is load l within load set L
- r ∈ G ∪ L is set of generation and load resources
- v ∈ VO is virtual offer v within virtual offer set VO
- v ∈ VB is virtual bid v within virtual bid set VB
- w ∈ WO is financial offer v within virtual offer set WO
- w ∈ WB is financial bid v within virtual bid set WB
- line ∈ N is transmission line within network N
- node ∈ N is network node within network N
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